Independently Excitable Resistivity Units

ABSTRACT

A downhole induction resistivity assembly that comprises a downhole tool string component. The tool string component comprises an induction transmitter. The transmitter is adapted to induce an induction field in the surrounding formation. A first induction receiver is spaced apart from the transmitter and is adapted to measure the induction field. A magnetic field generating mechanism is disposed adjacent on either or both sides of the transmitter and adapted to guide the transmitter&#39;s signal into the formation. A second induction receiver is disposed in close proximity to the magnetic field generating mechanism and is adapted to measure the magnetic field generated by the mechanism.

CROSS REFERENCE TO RELATED APPLICATIONS

This application is a continuation of U.S. patent application Ser. No.12/341,771 which is a continuation-in-part of U.S. patent applicationSer. No. 11/776,447 filed on Jul. 11, 1007 which claims priority toProvisional U.S. Patent Application No. 60/914,619 filed on Apr. 27,2007 and entitled Resistivity Tool. This application is also acontinuation-in-part of U.S. patent application Ser. Nos. 11/676,494;11/687,891; 61/073,190. All of the above mentioned references are hereinincorporated by reference for all that they contain.

BACKGROUND OF THE INVENTION

Electric resistivity of a downhole formation is often measured from awireline or drill string component in a well bore to analyze formationparameters. Induction resistivity tools induce a magnetic field into theformation; and thus, are different from laterlog resistivity systems,where an electric current is passed through the formation.

U.S. Pat. No. 6,677,756 to Fanini, et al, which is herein incorporatedby reference for all that it contains, discloses an induction tool forformation resistivity evaluations. The tool provides electromagnetictransmitters and sensors suitable for transmitting and receivingmagnetic fields in radial directions.

U.S. Pat. No. 6,359,438 to Bittar, which is herein incorporated byreference for all that it contains, discloses a resistivity tool for usein an LWD system that includes a transmitter array with multipletransmitters positioned above a pair of receivers. The transmitters areselectively energized, causing current to be induced in the collar ofthe tool.

U.S. Pat. No. 6,577,129 to Thompson, et al, which is herein incorporatedby reference for all that it contains, discloses an electromagnetic wavepropagation resistivity borehole logging system comprising multiplegroups of electromagnetic transmitter-receiver arrays operating at threefrequencies.

U.S. Pat. No. 6,538,447 to Bittar, which is herein incorporated byreference for all that it contains, discloses a multi mode resistivitytool for use in a loggingwhile-drilling system that includes anasymmetric transmitter design with multiple transmitters capable ofgenerating electromagnetic signals at multiple depths of investigation.

U.S. Pat. No. 7,141,981 to Folbert, et al, which is herein incorporatedby reference for all that it contains, discloses a resistivity loggingtool suitable for downhole use that includes a transmitter, and twospaced apart receivers. The measured resistivities at the two receiversare corrected based on measuring the responses of the receivers to acalibration signal.

U.S. Pat. No. 6,218,842 to Bittar, et al, which is herein incorporatedby reference for all that it contains, discloses a resistivity tool foruse in LWD systems that includes an asymmetric transmitter design withmultiple transmitters capable of generating EM signals at multiplefrequencies.

U.S. Pat. No. 5,045,795 to Gianzero, et al, which is herein incorporatedby reference for all that it contains, discloses a coil array which isinstalled on a MWD drill collar for use in a resistivity logging system.The drill collar is provided with upper and lower coil support rings.These are toroids which support individual coil segments, and areconnected by suitable magnetic shorting bars. The coil segments andshorting bars inscribe a specified solid angle or azimuthal extent.

U.S. Pat. No. 5,606,260 to Giordano, et al, which is herein incorporatedby reference for all that it contains, discloses a microdevice isprovided for measuring the electromagnetic characteristics of a mediumin a borehole. The microdevice includes at least one emitting ortransmitting coil (31), and at least one receiving coil (41,51). Themicrodevice generates an A.C. voltage at the terminals of thetransmitting coil and measures a signal at the terminals of thereceiving coil. The microdevice also includes an E-shaped electricallyinsulating, soft magnetic material circuit serving as a support for eachof the coils and which is positioned adjacent to the medium in theborehole.

U.S. Pat. No. 6,100,696 to Sinclair, which is herein incorporated byreference for all that it contains, discloses a directional inductionlogging tool is provided for measurement while drilling. This tool ispreferably placed in a side pocket of a drill collar, and it comprisestransmitter and receiver coils and an electromagnetic reflector.

U.S. Pat. No. 6,163,155 to Bittar, et al, which is herein incorporatedby reference for all that it contains, discloses a downhole method andapparatus for simultaneously determining the horizontal resistivity,vertical resistivity, and relative dip angle for anisotropic earthformations.

U.S. Pat. No. 6,476,609 to Bittar, et al, which is herein incorporatedby reference for all that it contains, discloses an antennaconfiguration in which a transmitter antenna and a receiver antenna areoriented in nonparallel planes such that the vertical resistivity andthe relative dip angle are decoupled.

BRIEF SUMMARY OF THE INVENTION

A downhole induction resistivity assembly comprises a downhole toolstring component. The tool string component comprises an inductiontransmitter. The transmitter is adapted to induce an induction field inthe surrounding formation. A first induction receiver is spaced apartfrom the transmitter and is adapted to measure the induction field. Amagnetic field generating mechanism is disposed adjacent on either orboth sides of the transmitter and adapted to guide the transmitter'ssignal into the formation. A second induction receiver is disposed inclose proximity to the magnetic field generating mechanism and isadapted to measure the magnetic field generated by the mechanism.

The magnetic field generating mechanism generates an augmented magneticfield. The mechanism generates a directed magnetic field. Someembodiments of either the magnetic field generating mechanism or theinduction transmitter may comprise: a Halbach array, a substantiallyU-shaped magnetic core, at least one coil disposed circumferentiallyabout the tool (wherein a magnetically conductive, electricallyinsulating material is disposed adjacent a surface of the component andthe coil), or some other magnetic field inducing mechanism.

The transmitter and/or at least one of the receivers may comprise amagnetic core disposed substantially parallel with an axis of the toolstring component. The transmitter and/or at least one of the receiversmay also comprise a plurality of circumferentially spaced units that areindependently excitable. The units may also be tilted with respect tothe central axis. The input and/or outputs from the units may bemultiplexed.

One of the receivers may comprise a core that is positionedsubstantially perpendicular to another induction resistivity receiver.The transmitter may be adapted to generate the induction field at adifferent phase, frequency, and/or amplitude than the mechanism isadapted to generate the magnetic field. The resistivity assembly maycomprise a control-loop adapted to execute a command to the mechanism toadjust a characteristic of the magnetic field, such characteristicsbeing selected from the group consisting of phases, amplitudes,frequencies, strength, or combinations hereof. The transceiver and/or atleast one of the receivers may comprise litz wire.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a cross-sectional diagram of an embodiment of a downhole toolstring.

FIG. 2 is a perspective diagram of an embodiment of tool stringcomponent.

FIG. 3 a is a perspective diagram of an embodiment of an inductiontransmitter.

FIG. 3 b is a perspective diagram of an embodiment of an inductionreceiver.

FIG. 4 a is a perspective diagram of an embodiment of an inductionresistivity assembly disposed downhole.

FIG. 4 b is a perspective diagram of another embodiment of an inductionresistivity assembly disposed downhole.

FIG. 5 a is a perspective diagram of another embodiment of an inductionreceiver.

FIG. 5 b is perspective diagram of another embodiment of an inductiontransmitter.

FIG. 5 c is a perspective diagram of another embodiment of an inductionreceiver.

FIG. 5 d is a perspective diagram of another embodiment of an inductiontransmitter.

FIG. 6 a is a perspective diagram of another embodiment of an inductiontransmitter.

FIG. 6 b is a perspective diagram of another embodiment of an inductionreceiver.

FIG. 7 a is a perspective diagram of another embodiment of an inductiontransmitter.

FIG. 7 b is a perspective diagram of another embodiment of an inductiontransmitter.

FIG. 8 a is a perspective diagram of another embodiment of an inductiontransmitter.

FIG. 8 b is a diagram of an embodiment of electronic assemblies disposedwithin a downhole component.

FIG. 9 is a perspective diagram of a downhole tool string component.

FIG. 10 a is a cross sectional diagram of a downhole tool stringcomponent.

FIG. 10 b is a cross sectional diagram of a downhole tool stringcomponent.

FIG. 10 c is a cross sectional diagram of a downhole tool stringcomponent.

FIG. 10 d is a cross sectional diagram of a downhole tool stringcomponent.

FIG. 11 a is a perspective diagram of a downhole tool string component.

FIG. 11 b is a perspective diagram of a downhole tool string component.

FIG. 12 a is a perspective diagram of a downhole tool string component.

FIG. 12 b is a plot of an embodiment of data gathered from a downholetool string component.

FIG. 13 is a perspective diagram of a downhole tool string component.

FIG. 14 a is a cross sectional diagram of a downhole tool stringcomponent.

FIG. 14 b is a cross sectional diagram of a downhole tool stringcomponent.

DETAILED DESCRIPTION OF THE INVENTION AND THE PREFERRED EMBODIMENT

Referring now to FIG. 1, a downhole tool string 101 may be suspended bya derrick 102. The tool string may comprise one or more downholecomponents 100, linked together in a tool string 101 and incommunication with surface equipment 103 through a downhole network.Networks in the tool string 101 may enable high-speed communicationbetween devices connected to the tool string, and the networks mayfacilitate the transmission of data between sensors and sources. Thedata gathered by the downhole components 100 may be processed downhole,may be transmitted to the surface for processing, may be filtereddownhole and then transmitted to the surface for processing or may becompressed downhole and then transmitted to the surface for processing.

FIG. 2 is an embodiment of a tool string component 100. The tool stringcomponent may comprise an induction transmitter 201 and a plurality ofinduction receivers 203. The receivers 203 may be placed in a variety oforientations with respect to each other and to the transmitter 201. Theinduction transmitter 201 is adapted b send an induction signal in tothe formation, which generates a formation induction field surroundingthe well bore. The induction receivers 203 are adapted to sense variousattributes of the induction field in the formation. These attributes mayinclude among others, some or all of the following: frequency,amplitude, or phase. The transmitter and the receivers may be powered bybatteries, a turbine generator or from the downhole network. Thereceivers may also be passive. In some embodiments, there may be severalinduction transmitters located along the length of the tool stringcomponent. In some embodiments, the additional transmitters may be usedto calibrate measurements, such as in common in borehole compensationtechniques.

The transmitter 201 and receivers 203 may communicate with the networkthrough a multiplexer 310. The receivers may be spaced along a centralaxis 1000 of the component 100 from the transmitter such that: a firstreceiver is spaced 10 to 14 inches 204 from the center of thetransmitter, a second receiver is spaced 16 to 20 inches 205 from thecenter of the transmitter, a third receiver is spaced 23 to 28 inches206 from the center of the transmitter, a fourth receiver is spaced 38to 43 inches 207 from the center of the transmitter, a fifth receiver isspaced 52 to 57 inches 208 from the center of the transmitter, and asixth receiver is spaced 77 to 82 inches 209 from the center of thetransmitter.

FIG. 3 a is a perspective view of an embodiment of a transmitter 201disposed within a drill string component and FIG. 3 b is a perspectiveview of an embodiment of three receivers 202, 203, and 304. Thetransmitter 201 may comprise an array of transmitter units 301 spacedcircumferentially around the tool string 100. The transmitter units 301may lie parallel to the body of the drill string. The transmitter units301 may be independently excitable. Independently excitable units mayfocus the induction field in only a portion of the formation adjacent tothe excitable units while the remaining portion of the formation isminimally affected or not affected at all. Furthermore it is believedthat the ability to concentrate the field in portions of the formationadjacent the well bore will allow for directional measurements of theformation. Data received through directional measurement may verify acurrent drilling trajectory or it may reveal needed adjustments.Steering adjustments may be made by a steering system in communicationwith a downhole communication system, such as the system disclosed inU.S. Pat. No. 6,670,880, which is herein incorporated by reference forall that it discloses. An embodiment of a compatible steering system isdisclosed in U.S. patent application Ser. No. 12/262,372 to Hall et al.,which is herein incorporated by reference for all that it contains.

The transmitter 201 may also comprise a magnetic field generatingmechanism 302, which may guide the induction field produced by thetransmitter units 301 by forcing the transmitter's signal deeper intothe formation The windings on the transmitter 201 may be in a differentdirection then the windings on the magnetic field generating mechanism302. In some embodiments, the magnetic field generating mechanism 302may generate an augmented field or a directed field. Examples ofmagnetic field generating mechanism that may be used to influence thesignal from the transmitter include Hallbach arrays, electric magnets,and directed magnetic field. Without the magnetic field generatingmechanism 302 the transmitter's signal may travel along the path of lestresistance which could be within a shallower region of the formation oreven along the surface of the tool string component. The magnetic fieldgenerating mechanism 302 may generate a magnetic field that will repelthe signal away from the tool string component, and thus, deeper intothe formation. The magnetic field generating mechanism 302 may have astartup sequence such that when the transmitter 201 first starts areference receiver 202 measures the field strength and through a controlloop adjusts the output of the magnetic field generating mechanism 302until the field measured by the reference receiver 202 is at a desiredstrength. The magnetic field generating mechanisms 302 may also haveunits that are independently excitable with respect to phase, frequency,or magnitude.

The reference receiver 202 may be disposed in the tool string componentin close proximity to the magnetic field generating mechanism 302. Thereference receiver is close enough to the mechanism 302 that it isexcitable by the magnetic field generating mechanism, not just theinduction field that is regenerated in the formation The other receiversmay be less sensitive to the induction field generated in the formation.Thus, the reference receiver may determine the strength, magnitude,phase, and other parameters of the magnetic field generating device'ssignal. If the mechanism 302 produces a magnetic field that is too weakthe magnetic field may be ineffective, and if the magnetic field is toostrong it may inhibit the transmitter's induction field from penetratingthe formation at all. Such parameters may be used to adjust the magneticfield generating device to produce an optimal signal for the desiredpenetration of the induction field into the formation. The resistivitytool may comprise a control loop that is adapted to execute a command toadjust at least one parameter of the magnetic field generatingmechanism; the characteristics may be selected from the group consistingof phases, amplitudes, frequencies, strength, or combinations thereof.In some embodiments the telemetry system may include mud pulse, EM,short-hop, and/or wired pipe, the command to adjust the signal may befrom surface equipment or generated downhole. In some embodiments, thesignal is executed automatically or it may be executed manually.

In some embodiments, the reference receiver may be capable of sensingboth the magnetic field and the induction field. In such cases, thesignals from the transmitter and the magnetic field generating devicemay comprise different parameters such as different frequencies,different phases, different amplitude, and/or signal strength so thatthe signals may be distinguishable. In some embodiment, the otherreceivers may also be close enough to sense the magnetic field.

The reference receiver may be comprised of an array of referencereceiver units 303. The receiver units 202 may lie substantiallyparallel to a longitudinal axis of the body of the tool stringcomponent. The reference receiver may comprise a spool receiver 304 thatmay comprise a magnetically conductive core that is disposedperpendicular to the body of the drill string and another inductionresistivity receiver. The spool receiver 304 may be part of a referencereceiver assembly. Since the core of the spool receiver and the receiverunits lie on different planes they sense boundaries of the subterraneanformation that the other cannot. In some embodiments, the receiver unitsand the core of the spool receiver are oriented such that they are notsubstantially perpendicular to each other, but are still adapted tosense boundary between subterranean strata at different angles.

Referring now to FIG. 4 a, an embodiment of a tool string component isdepicted in a borehole. The drill string component comprises atransmitter 201, a reference receiver 202, and receivers 203. Thetransmitter is depicted generating an induction signal 401 with themagnetic field generating mechanism 302 being inactive. Drilling mud 402is disposed between the tool string component and the formation 403. Themagnetic field 401 may tend to predominately travel within the bore holeor within a shallow portion of the formation infiltrated by drilling mudand may not penetrate deeply into the formation 403. This may prevent anactual depiction of the formation surrounding the bore hole. FIG. 4 bdepicts an embodiment of a tool string component with both thetransmitter unit 301 and the magnetic field generating mechanism 302activated, which shows the induction signal traveling deeper in theformation. It is believed that by adjusting the output of the magneticfield generating mechanism 302 the penetration depth of the inductionsignal 401 may be adjusted. The magnetic field generating mechanisms 302may be positioned on both sides of the transmitter 201.

FIG. 5 a discloses an embodiment of a spool receiver 304. The spoolreceiver may comprise a ferrite core 506 wrapped in wire 504. FIG. 5 bdiscloses an embodiment of a magnetic field generating mechanism 302.The mechanism may comprise a U-shaped ferrite core 507 wrapped in wire509. FIG. 5 c discloses an embodiment an independently excitable unit ofa receiver 305 and/or transmitter with a ferrite core 502 wrapped inwire 505. FIG. 5 d discloses an embodiment of a transmitter 301 and/orreceiver. The spool receiver may comprise a ferrite core 500 wrapped inwire 501. In some embodiments, the wire depicted in FIGS. 5 a-d may beLitz wire. In some embodiments, the wire windings on the variouscomponents may be wrapped in different directions or different patternsthen each other.

FIG. 6 a depicts an embodiment of a portion of a tool string component100. In this embodiment the transmitter units 301 and the magnetic fieldgenerating mechanisms 302 are tilted with respect to a central axis ofthe tool string 100. In FIG. 6 b an embodiment of a portion of a toolstring component 100 discloses the reference receiver units 303 and thereceiver units 305 tilted with respect to a central axis of a toolstring component. The tilt angle may be at any degree. In someembodiments, the tilt angle is between 10 and 50 degrees with respect tothe central axis.

FIG. 7 a is an embodiment of a transmitter 201 disposed on a tool stringcomponent 100. In this embodiment the transmitter units 701 comprises aHalbach array. FIG. 7 b is an embodiment of a transmitter 201 disposedon a tool string component 100. In this embodiment the magnetic fieldgenerating mechanism 702 comprises a Halbach array. It is believed thatthe Halbach array will direct a greater magnitude of the magnetic fieldfor a given power into the formation then a standard transmitter.

FIG. 8 a depicts an embodiment of a transmitter 201 where thetransmitter comprises wire windings 803 wound circumferentially aroundthe tool string component 100. The wire is disposed within a trough ofmagnetically conductive, electrically insulating (MCEI) material 1800that is disposed adjacent a surface of the component and the coil. TheMCEI material may comprise mu-metals, ferrite, and/or iron. Anembodiment of a transmitter that may be compatible with the presentinvention is disclosed in U.S. patent application Ser. No. 11/676,494,which is herein incorporated by reference for all that it discloses.

FIG. 8 b discloses an embodiment of a portion of a tool string component100. The tool string 100 may comprise a multiplexer 801. The multiplexermay be adapted to take data from multiple inputs and put all of the dataonto a lesser number of outputs. The tool string component may alsocomprise a processing element 802. The processing element 802 may beadapted to process data and send out commands to the tool string 100.That data may comprise among other data any or all of the following:data from the receivers, data from the reference receiver, or data fromthe transmitter. The processing element 802 may send commands to asteering assembly to guide the tool string 100 in a desired direction.

FIG. 9 is a perspective diagram of a downhole tool string component 100in operation downhole. The tool string component 100 is connected to adrill bit 900 comprising a steering mechanism 901 protruding beyond thefront face of the bit. Also shown are a plurality of receivers 203disposed along the tool string component and the drill bit. Thereceivers may be positioned on different downhole components or they maybe positioned along a single downhole component. The farthest mostreceiver 902 from the transmitter (not shown in FIG. 9) may be disposedon the drill bit and positioned between the wrench flats 903 of thedrill bit and the drill bit's cutting blades 904. The resistivity toolmay be used for geo-steering applications where it is desirable to staywithin a specific formation layer. The resistivity tool may helpidentify the formation type boundaries. In embodiments where theresistivity tool is connected to a feed back loop, a command may be sentfrom a processing element associated with the resistivity tool to asteering system to adjust the tool string's trajectory to keep the toolstring within the preferred layer. In some embodiments, data from theresistivity tool may be received up-hole through a telemetry system andadjustments to the steering may be executed remotely. Data may begathered from any of the sensors while the drill bit is rotating, whilethe drill bit is sliding, or while the drill bit is stationary. A rotarysteerable system that may be compatible with the present invention isdisclosed in U.S. Pat. No. 7,360,610, which is herein incorporated byreference for all that it discloses.

FIGS. 10 a, 10 b, 10 c, and 10 d are cross sectional views of a downholecomponent depicting the individually excitable induction units 301. Insome embodiments, these units 301 may be excited at once, in pairs, ingroups, or individually. In some applications it may be desirable toanalyze only a portion of the borehole wall. In some applications, whereaccuracy is critical, the drill string may be stopped, and the units maybe individually activated. In other embodiments, a single unit may beactivated while the drill string rotates, and thus, induces an inductionfield around the entire circumference of the bore hole. The transmitterunits 301 may be activated in a number of different orders. Theactivation orders may include but are not limited to the orders depictedin FIGS. 10 a, 10 b, 10 c, and 10 d. The transmitter segments 301 may beactivated in a clockwise or counter clockwise direction.

FIG. 11 a depicts an embodiment of an irradiated plastic cover 1201disposed around a tool string component 100. It is believed that theirradiated plastic cover 1201 may protect the transmitters andreceivers. It is also believed the cover 1201 will minimally interferewith the induction waves. The cover 1201 may comprise a materialselected from a group of thermoplastic polymers. The cover may comprisea polytheretherkekytone (PEEK) material. In some embodiments, theplastic may comprise glass filled PEEK, glass filled Torlon®, Torlon®,polyamide-imide, glass filled polyamide-imide, thermoplastic,polyimides, polyamides or combinations thereof. The cover material mayhave a melting point between 333.9 degrees Celsius and 350 degreesCelsius. The cover material may have a tensile strength of between 70megapascals and 100 megapascals. The cover may take the form of a sleevedisposed around the tool string component. The cover may compriseirradiated plastic windows 1202.

FIG. 11 b depicts an embodiment of a data gathering technique. In thistechnique a single transmitter segment 1201 in activated and thegenerated signal 1125 is gathered by an individual receiver segment1202. The receiver segment 305 that is used to gather the signal 1125may be at the same azimuth as the activated transmitter segment 1201.The non data gathering receiver segments may be deactivated or ignored.This process is repeated with a different set of receivers andtransmitters. In some applications, a portion or all of the transmittersand receivers may be used. Data received at a receiver unit 1203 on adifferent azimuth that the transmitter unit 1201 may provide angulardata that may correspond to a dip angle 1150 (see FIG. 12 b) of aformation.

In FIG. 12 a, the transmitter segment 1100 generates signal 1110 whichis received by receiver segment 1105, then transmitter segment 1101generates signal 1111 which is received by receiver segment 1106, thentransmitter segment 1102 generates signal 1112 which is received byreceiver segment 1107, and finally transmitter segment 1103 generatessignal 1113 which is received by receiver segment 1108. An embodiment ofthe gathered data is plotted in FIG. 12 b. The plots may correspond tothe gathered data such that plot 1123 corresponds to signal 1110, plot1122 corresponds to signal 1111, plot 1121 corresponds to signal 1112,and plot 1120 corresponds to signal 1113. The plots may be versus eithertime or frequency. It is believed that the plots will have an offset1160 with respect to each other. It is believed that the offset 1160 ofeach consecutive recorded signal 1125 may be extrapolated to form a line1152 of a certain slope. It is further believed that this line 1152 willform an angle 1151 that is mathematically related to the dip angle 1150of the formation. In FIG. 12 b, only a portion of the extrapolated lineis shown, which if fully represented would appear as a sine wave than astraight line.

FIG. 13 depicts another embodiment of a data gathering technique. Inthis technique a transmitter segment 301 is activated and a first and asecond receiver assembly 202 capture the data. The data received fromthe first receiver contains information that corresponds to theformation 1301 that is adjacent to the tool string component 100 betweenthe transmitter 201 and the first receiver. The data received from thesecond receiver contains information that corresponds to the formation1302 that is adjacent to the tool string component 100 between thetransmitter 201 and the second receiver. This data gathering techniqueutilizes mathematical operations to extract the information thatcorresponds to the formation 1305 lying predominately adjacent to thetool string 100 between the first receiver and the second receiver.

FIGS. 14 a and 14 b depict different embodiments of receiver segments305. The receiver segments 305 may be independently excitable. Thereceiver segments 305 may be electronically deactivatable. The receiversegments may also be tunable such that a virtual receiver segment 1401is created. A virtual receiver segment 1401 may be created when twoadjacent receiver segments adjust their power such that a virtualreceiver 1401 can be modeled as be positioned between the two segments305. FIG. 14 a depicts an embodiment of a virtual receiver that is theresult of the data received by two adjacent receivers 305 being equallyweighted. FIG. 14 b depicts an embodiment of a virtual receiver 1402that is the result of the data received by segment 1403 being weighedmore heavily then the data received by segment 1404. The virtualreceiver 1402 in this case appears closer to segment 1403 than in FIG.14 a.

Whereas the present invention has been described in particular relationto the drawings attached hereto, it should be understood that other andfurther modifications apart from those shown or suggested herein, may bemade within the scope and spirit of the present invention.

1. A downhole induction resistivity assembly, comprising: a downholetool string component comprising an induction transmitter on thecomponent, the transmitter being adapted to induce an induction field inthe formation; a plurality of induction receivers being spaced apartfrom the transmitter and being adapted to measure the induction field;and the transmitter and/or at least one of the receivers comprise aplurality of units that are independently excitable.
 2. The assembly ofclaim 1, wherein a magnetic field generating mechanism is disposedadjacent to the transmitter and adapted to guide the transmitter'ssignal into the formation.
 3. The assembly of claim 2, wherein a closestinduction receiver of the plurality to the transmitter is adapted tomeasure the magnetic field generated by the mechanism.
 4. The assemblyof claim 2, wherein the magnetic field generating mechanism isindependently excitable from the transmitter units.
 5. The assembly ofclaim 2, wherein the mechanism generates an augmented magnetic field. 6.The assembly of claim 2, wherein the mechanism comprises a Halbacharray.
 7. The assembly of claim 2, wherein the mechanism generates adirected magnetic field.
 8. The assembly of claim 2, wherein themechanism comprises a substantially U-shaped magnetic core.
 9. Theassembly of claim 1, wherein the units are tilted with respect to acentral axis of the component.
 10. The assembly of claim 1, wherein theunits are substantially parallel with respect to a central axis of thecomponent.
 11. The assembly of claim 1, wherein an individual unit ofthe plurality is adapted to only induce a portion of the formation insubstantially a single direction.
 12. The assembly of claim 1, whereinan individual unit of the plurality is adapted to induce only a portionof the formation associated with a fraction of the boreholecircumference.
 13. The assembly of claim 1, wherein at least one of theplurality of receivers is located on a drill bit connected to a stringof drilling components.
 14. The assembly of claim 1, wherein theassembly comprises a processing element adapted to send/receive commandsto with a steering assembly associated with a string of drillingcomponents.
 15. A method for using a downhole induction resistivityassembly, comprising: providing a downhole tool string componentcomprising an induction transmitter on the component, at least oneinduction receiver is spaced apart from the transmitter, and thetransmitter and/or at least one receiver comprises a plurality of unitsthat are independently excitable inducing an induction field into theformation by exciting the one of the units in the transmitter; andmeasuring the induction field with the at least one receiver.
 16. Themethod of claim 15, wherein the units of the transmitter are spacedalong a circumference of the tool string component.
 17. The method ofclaim 15, wherein a unit of the transmitter is excited and a unit of thereceiver substantially positioned on a same azimuth of the tool stringcomponent is adapted to measure the induction field.
 18. The method ofclaim 15, wherein a unit of the transmitter is excited and a unit of thereceiver substantially positioned on a different azimuth of the toolstring component is adapted to measure the induction field.
 19. Themethod of claim 15, wherein the transmitter units are excited in apre-determined sequence.
 20. The method of claim 19, wherein thepre-determined sequence between different sides of the transmitter.